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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

Form 10-Q

For the Quarterly Period Ended March 31, 2003

or

Commission file number 000-24890

EDISON MISSION ENERGY
(Exact name of registrant as specified in its charter)

Registrant's telephone number, including area code: (949) 752-5588

        Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. YES ý NO o

        Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). YES o NO ý

        Number of shares outstanding of the registrant's Common Stock as of May 14, 2003: 100 shares (all shares held by an affiliate of the registrant).

TABLE OF CONTENTS

PART I—FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EDISON MISSION ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(In thousands)

The accompanying notes are an integral part of these consolidated financial statements.

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EDISON MISSION ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(In thousands)

The accompanying notes are an integral part of these consolidated financial statements.

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EDISON MISSION ENERGY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In thousands)

The accompanying notes are an integral part of these consolidated financial statements.

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EDISON MISSION ENERGY AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(In thousands)

The accompanying notes are an integral part of these consolidated financial statements.

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EDISON MISSION ENERGY AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

The accompanying notes are an integral part of these consolidated financial statements.

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EDISON MISSION ENERGY AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

MARCH 31, 2003

(Dollars in millions)

Note 1. General

        In the opinion of management, all adjustments, including recurring accruals, have been made that are necessary to present fairly the consolidated financial position and results of operations for the periods covered by this report. The results of operations for the three months ended March 31, 2003 are not necessarily indicative of the operating results for the full year.

        Edison Mission Energy's (EME's) significant accounting policies are described in Note 2 to its Consolidated Financial Statements as of December 31, 2002 and 2001, included in EME's annual report on Form 10-K for the year ended December 31, 2002. EME follows the same accounting policies for interim reporting purposes. This quarterly report should be read in connection with such financial statements.

        Terms used but not defined in this report are defined in EME's annual report on Form 10-K for the year ended December 31, 2002. Certain prior period amounts have been reclassified to conform to the current period financial statement presentation. These reclassifications had no effect on net income or shareholder's equity.

Current Developments

        A number of significant developments during late 2001 and 2002 adversely affected independent power producers and subsidiaries of major integrated energy companies that sell a sizable portion of their generation into the wholesale energy market (sometimes referred to as merchant generators), including several of EME's subsidiaries. These developments included lower market prices in wholesale energy markets both in the United States and United Kingdom, significant declines in the credit ratings of most major market participants, decreased availability of debt financing or refinancing, and a resulting decline of liquidity in the energy markets due to growing concern about the ability of counterparties to perform their obligations. Since the beginning of 2003, several merchant generators reached agreements to extend existing bank credit facilities.

        EME's largest subsidiary, Edison Mission Midwest Holdings, has $911 million of debt maturing in December 2003 which will need to be repaid, extended or refinanced. Edison Mission Midwest Holdings is not expected to have sufficient cash to repay the $911 million debt due in December 2003, and there is no assurance that Edison Mission Midwest Holdings will be able to extend or refinance its debt obligation on similar terms and rates as the existing debt, on commercially reasonable terms, on the terms permitted under the financing documents entered into by EME's parent company, Mission Energy Holding Company, in July 2001, or at all. EME's independent accountants' audit opinion for the year ended December 31, 2002 contains an explanatory paragraph that indicates the consolidated financial statements have been prepared on the basis that EME will continue as a going concern and that the uncertainty about Edison Mission Midwest Holdings' ability to repay, extend or refinance this obligation raises substantial doubt about EME's ability to continue as a going concern. Accordingly, the consolidated financial statements do not include any adjustments that might result from the resolution of this uncertainty.

        During the first quarter of 2003, wholesale energy prices in the Pennsylvania-New Jersey-Maryland Power Pool, or PJM, increased primarily due to colder-than-normal weather and increases in the prices for natural gas. However, the recent changes in wholesale energy prices may or may not continue

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throughout 2003. See "Item 2. Management's Discussion and Analysis of Results of Operations and Financial Condition—Market Risk Exposures" for more information regarding forward market prices.

Note 2. Acquisitions and Dispositions

Acquisitions

        On March 3, 2003, Contact Energy, EME's 51% owned subsidiary, completed a transaction with NGC Holdings Ltd. to acquire the Taranaki Combined Cycle power station and related interests. The Taranaki station is a 357 MW combined cycle, natural gas-fired plant located near Stratford, New Zealand. Consideration for the Taranaki station consisted of a cash payment of approximately $275 million, which was financed with bridge loan facilities. The bridge loan facilities were subsequently repaid with proceeds from the issuance of long-term U.S. dollar denominated notes.

Dispositions

        During the first quarter of 2002, EME completed the sales of its 50% interests in the Commonwealth Atlantic and James River projects and its 30% interest in the Harbor project. Proceeds received from the sales were $44 million. During 2001, EME recorded asset impairment charges of $32 million related to these projects based on the expected sales proceeds. No gain or loss was recorded from the sale of EME's interests in these projects during the first quarter of 2002.

Note 3. Goodwill and Intangible Assets

        Effective January 1, 2002, EME adopted Statement of Financial Accounting Standards No. 142, "Goodwill and Other Intangible Assets." SFAS No. 142 establishes accounting and reporting standards requiring goodwill not to be amortized but rather tested for impairment at least annually at the reporting unit level. EME will perform its annual evaluation of goodwill on October 1, 2003 or sooner if indicators of impairment exist. During the third quarter of 2002, EME concluded that fair value of the goodwill related to the Citizens Power LLC acquisition was impaired by $14 million, net of $9 million of income tax benefit and, accordingly, reported this amount as a cumulative change in accounting. In accordance with SFAS No. 3, "Reporting Accounting Changes in Interim Financial Statements," EME's financial statements for the first quarter of 2002 were restated to reflect the accounting change as of January 1, 2002.

        Included in "Restricted cash and other assets" on EME's consolidated balance sheet are customer contracts with a gross carrying amount of $87 million and accumulated amortization of $6 million at March 31, 2003. The contracts have a weighted average amortization period of 20 years. For the three months ended March 31, 2003, the amortization expense was $1 million. Based on the current amount of intangible assets subject to amortization, the estimated amortization expense for fiscal years 2004 through 2008 is $5 million each year. Intangible assets classified in "Restricted cash and other assets" of $1 million at March 31, 2003 consists of an additional minimum pension liability at Midwest Generation.

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        Changes in the carrying amount of goodwill, by geographical segment, for the three months ended March 31, 2003 are as follows:

(1)

Represents goodwill resulting from Contact Energy's acquisition of the Taranaki station in March 2003.

Note 4. Inventory

        Inventory is stated at the lower of weighted average cost or market. Inventory at March 31, 2003 and December 31, 2002 consisted of the following:

Note 5. Accumulated Other Comprehensive Income (Loss)

        Accumulated other comprehensive income (loss) consisted of the following:

        Unrealized gains (losses) on cash flow hedges included those related to the hedge agreement with the State Electricity Commission of Victoria for electricity prices from the Loy Yang B project in Australia. This contract does not qualify under the normal sales and purchases exception because financial settlement of the contract occurs without physical delivery. These losses arise because current forecasts of future electricity prices in these markets are greater than contract prices. In addition to this contract, unrealized gains (losses) on cash flow hedges included those related to EME's share of interest rate swaps of its unconsolidated affiliates and the Loy Yang B project.

        As EME's hedged positions are realized, approximately $10 million, after tax, of the net unrealized losses on cash flow hedges at March 31, 2003 are expected to be reclassified into earnings during the next 12 months. Management expects that when the hedged items are recognized in earnings, the net unrealized losses associated with them will be offset. The maximum period over which EME has designated a cash flow hedge, excluding those forecasted transactions related to the payment of variable interest on existing financial instruments, is 14 years. Actual amounts ultimately reclassified into earnings over the next 12 months could vary materially from this estimated amount as a result of changes in market conditions.

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        Under SFAS No. 133, the portion of a cash flow hedge that does not offset the change in value of the transaction being hedged, which is commonly referred to as the ineffective portion, is immediately recognized in earnings. EME recorded a net loss of approximately $8 million and $1 million during the first quarters of 2003 and 2002, respectively, representing the amount of cash flow hedges' ineffectiveness, reflected in net gains (losses) from price risk management and energy trading in EME's consolidated income statement.

Note 6. Discontinued Operations

Lakeland Project

        EME's Lakeland project operated a 220 MW combined cycle, natural gas-fired power plant located in the United Kingdom. The assets of the project are owned by EME's indirect subsidiary, Lakeland Power Ltd., which sold power generated from the plant pursuant to a power sales agreement with Norweb Energi Ltd., a subsidiary of TXU (UK) Holdings Limited (TXU UK) and an indirect subsidiary of TXU Europe Group plc (TXU Europe).

        On December 19, 2002, the lenders to the Lakeland project accelerated the debt owing under the bank agreement that governs the project's indebtedness, and on December 20, 2002, the Lakeland project lenders appointed an administrative receiver over the assets of Lakeland Power Ltd. The administrative receiver was appointed to take control of the affairs of Lakeland Power Ltd. and has a wide range of powers (specified in the Insolvency Act), including authorizing the sale of the power plant. The appointment of the administrative receiver requires the treatment of Lakeland power plant as an asset held for sale under Statement of Financial Accounting Standards No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets" (SFAS No. 144). Due to EME's loss of control arising from the appointment of the administrative receiver, EME no longer consolidates the activities of Lakeland Power Ltd. The consolidated financial statements have been restated to conform to discontinued operations treatment for all historical periods presented.

        On April 22, 2003, a third party announced that it had entered an agreement with the administrative receiver to purchase the Lakeland power plant for £24 million. Subject to satisfaction of closing conditions, completion of the sale is expected during the second quarter of 2003.

Ferrybridge and Fiddler's Ferry Plants

        On December 21, 2001, EME completed the sale of the Ferrybridge and Fiddler's Ferry coal-fired power plants located in the United Kingdom to two wholly owned subsidiaries of American Electric Power. In addition, as part of the transactions, the purchasers acquired other assets and assumed specified liabilities associated with the plants. The sale was the result of a competitive bidding process. EME acquired the plants in 1999 from PowerGen UK plc for £1.3 billion. In accordance with SFAS No. 144, the results of Ferrybridge and Fiddler's Ferry have been reflected as discontinued operations in EME's consolidated financial statements. The consolidated financial statements have been restated to conform to discontinued operations treatment for all historical periods presented.

        Summarized results of discontinued operations are as follows:

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        The following summarizes the balance sheet information of the discontinued operations:

Note 7. Commitments and Contingencies

Commercial Commitments

        The following table summarizes EME's consolidated commercial commitments as of March 31, 2003. Details regarding these commercial commitments are discussed in the sections following the table.

Firm Commitments to Contribute Project Equity

(i)

CBK is a 755 MW hydroelectric power project under construction in the Philippines. At March 31, 2003, 380 megawatts have been commissioned and are operational. A wholly owned subsidiary of EME owns a 50% interest. For further discussion on recent developments related to the CBK project, see "Item 2. Management's Discussion and Analysis of Results of Operations and Financial Condition—Liquidity and Capital Resources—Historical Distributions Received by Edison Mission Energy—CBK Project."

(ii)

The Sunrise project, located in Fellows, California, consists of two phases: Phase 1, a simple-cycle gas-fired facility (320 MW) that commenced commercial operation in June 2001; and Phase 2, conversion to a combined-cycle gas-fired facility (bringing the plant to a total capacity of 560 MW) currently scheduled to be completed in July 2003. A wholly owned subsidiary of EME owns a 50% interest. Equity will be contributed to fund the construction of Phase 2. The amount set forth in

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the above table assumes the partners will contribute equity for the entire construction cost. For more information on the Sunrise project financing, see "Item 2. Management's Discussion and Analysis of Results of Operations and Financial Condition—Liquidity and Capital Resources—Subsidiary Financing Plans—Sunrise Project Financing."

        Firm commitments to contribute project equity to the CBK project could be accelerated due to events of default as defined in the non-recourse project financing facilities.

Contingencies

Legal Developments Affecting Sunrise Power Company

        Sunrise Power Company, in which EME's wholly owned subsidiary owns a 50% interest, sells all its output to the California Department of Water Resources under an eleven-year power purchase agreement entered into on June 25, 2001 and restructured on December 31, 2002. In January 2003, the California Public Utilities Commission and the California Electricity Oversight Board dismissed the complaints they had filed with the Federal Energy Regulatory Commission against Sunrise Power Company, alleging that the contract was "unjust and unreasonable."

        On May 2, 2002, the United States Justice Foundation announced that it had filed a complaint in the Superior Court of the State of California, Los Angeles County, against the California Department of Water Resources, all sellers of power under long-term energy contracts entered into in 2001, including Sunrise Power Company, and Vikram Budhraja, one of the consultants involved in the negotiation of energy contracts on behalf of the California Department of Water Resources. The lawsuit asks the Superior Court to void all the contracts entered into in 2001, as well as all the contracts renegotiated in 2002, as a result of a purported conflict of interest by Mr. Budhraja. Sunrise Power Company has not yet been served with the complaint.

        On May 15, 2002, Sunrise Power Company was served with a complaint filed in the Superior Court of the State of California, City and County of San Francisco, by James M. Millar, "individually, and on behalf of the general public and as a representative taxpayer suit" against sellers of long-term power to the California Department of Water Resources, including Sunrise Power Company. The lawsuit alleges that the defendants, including Sunrise Power Company, engaged in unfair and fraudulent business practices by knowingly taking advantage of a manipulated power market to obtain unfair contract terms. The lawsuit seeks to enjoin enforcement of the "unfair and oppressive terms and conditions" in the contracts, as well as restitution by the defendants of excessive monies obtained by the defendants. Plaintiffs in several other class action lawsuits pending in Northern California have filed petitions seeking to have the Millar lawsuit consolidated with those lawsuits. The defendants in the Millar lawsuit and other class action suits removed all the lawsuits to the U.S. District Court, Northern District of California, and filed a motion to stay all proceedings pending final resolution of the jurisdictional issue. Various plaintiffs have filed pleadings opposing the removal and requesting that the matters be remanded to state court. The motions are still pending. EME believes that the outcome of this litigation will not have a material adverse effect on its consolidated financial position or results of operations.

Regulatory Developments Affecting Doga Project

        On August 4, 2002, a new Electricity Market License Regulation was implemented in Turkey. The regulation contains, among other things, a requirement for each generator to obtain a generation license. Historically, Doga's Implementation Contract has been its sole license. The new regulation contemplates an initial fixed license fee and a yearly license fee based on the amount of energy generated, which will increase the project's costs of operation by an undetermined amount. In addition, the regulation allows the insertion of provisions in the license which are different from those in the Implementation Contract.

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        The effect of the new regulation is still undetermined, as the new license provisions have not been specified. The new regulation requires Doga to apply for a generation license by June 2, 2003. If actions or inactions undertaken pursuant to the new regulation directly or indirectly impede, hinder, prevent or delay the operation of the Doga facility or increase Doga's cost of performing its obligations under its project documents, this may constitute a risk event under Doga's Implementation Contract. A risk event may permit Doga to request an increase in its tariff or, under certain circumstances, request a buyout of the project by the Ministry of Energy and Natural Resources.

        On October 3, 2002, Doga and several other independent power producers filed a lawsuit in the Danistay, Turkey's high administrative court, against the Energy Market Regulatory Authority seeking invalidation of certain provisions of the new regulation, arguing the unconstitutionality of the imposition of new license requirements that do not take into account the vested rights of companies presently performing electricity generation pursuant to previously agreed conditions. No decision has been rendered, and discussions with the Turkish authorities continue.

Federal Income Taxes

        EME is, and may in the future be, under examination by tax authorities in varying tax jurisdictions with respect to positions it takes in connection with the filing of its tax returns. Matters raised upon audit may involve substantial amounts, which, if resolved unfavorably, an event not currently anticipated, could possibly be material. However, in EME's opinion, it is unlikely that the resolution of any such matters will have a material adverse effect upon EME's financial condition or results of operations.

Litigation

        EME experiences other routine litigation in the normal course of its business. None of such pending routine litigation is expected to have a material adverse effect on EME's consolidated financial position or results of operations.

Guarantees and Indemnities

Tax Indemnity Agreements

        In connection with the sale-leaseback transactions that EME has entered into related to the Collins Station, Powerton and Joliet plants in Illinois and the Homer City facilities in Pennsylvania, EME or one of its subsidiaries has entered into tax indemnity agreements. Under these tax indemnity agreements, EME has agreed to indemnify the lessors in the sale-leaseback transactions for specified adverse tax consequences that could result in certain situations set forth in each tax indemnity agreement, including specified defaults under the respective leases. The potential indemnity obligations under these tax indemnity agreements could be significant. Due to the nature of these obligations under these tax indemnity agreements, EME cannot determine a maximum potential liability. The indemnities would be triggered by a valid claim from the lessors. EME has not recorded a liability related to these indemnities.

Indemnities Provided as Part of the Acquisition of the Illinois Plants

        In connection with the acquisition of the Illinois Plants, EME agreed to indemnify Commonwealth Edison against damages, claims, fines, liabilities and expenses and losses arising from, among other things, environmental liabilities before and after the date of sale as specified in the Asset Sale Agreement dated March 22, 1999. The indemnification claims are reduced by any insurance proceeds and tax benefits related to such claims and are subject to a requirement by Commonwealth Edison to take all reasonable steps to mitigate losses related to any such indemnification claim. Due to the nature of the obligation under this indemnity, a maximum potential liability cannot be determined. The indemnification for the environmental liabilities referred to above is not limited in term and would be

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triggered by a valid claim from Commonwealth Edison. Except as discussed below, EME has not recorded a liability related to this indemnity.

        Midwest Generation entered into a supplemental agreement on February 20, 2003 to resolve a dispute regarding interpretation of its reimbursement obligation for asbestos claims under the environmental indemnities set forth in the Asset Sale Agreement. Under this supplemental agreement, Midwest Generation agreed to reimburse Commonwealth Edison 50% of specific existing asbestos claims less recovery of insurance costs, and agreed to a sharing arrangement for liabilities associated with future asbestos related claims as specified in the agreement. The obligations under this agreement are not subject to a maximum liability. The supplemental agreement has a five-year term with an automatic renewal provision (subject to the right to terminate). Payments are made under this indemnity by a valid claim provided from Commonwealth Edison. At March 31, 2003, Midwest Generation recorded a $5 million liability related to known claims provided by Commonwealth Edison.

Indemnity Provided as Part of the Acquisition of the Homer City Facilities

        In connection with the acquisition of the Homer City facilities, EME Homer City Generation L.P. is obligated to indemnify the sellers against damages, claims and losses arising from environmental liabilities before and after the date of sale as specified in the Asset Purchase Agreement dated August 1, 1998. EME guaranteed the obligations of EME Homer City. Due to the nature of the obligation under this indemnity provision, it is not subject to a maximum potential liability nor has an expiration date. Payments would be triggered under this indemnity by a claim from the sellers. EME has not recorded a liability related to this indemnity.

Indemnities Provided Under Asset Sale Agreements

        In connection with the sale of assets, EME has provided indemnities to the purchasers for taxes imposed with respect to operations of the asset prior to the sale, and EME or its subsidiaries have received similar indemnities from purchasers related to taxes arising from operations after the sale. EME has also provided indemnities to purchasers for items specified in each agreement (for example, specific pre-existing litigation matters and/or environmental conditions). Due to the nature of the obligations under these indemnity agreements, a maximum potential liability cannot be determined. Not all indemnities under the asset sale agreements have specific expiration dates. Payments would be triggered under these indemnities by valid claims from the sellers or purchasers, as the case may be. EME has not recorded a liability related to these indemnities.

Guarantee of Brooklyn Navy Yard Contractor Settlement Payments

        Brooklyn Navy Yard is a 286 MW gas-fired cogeneration power plant in Brooklyn, New York. EME's wholly owned subsidiary owns 50% of the project. In February 1997, the construction contractor asserted general monetary claims under the turnkey agreement against Brooklyn Navy Yard Cogeneration Partners, L.P. A settlement agreement was executed on January 17, 2003, and all litigation has been dismissed. EME has indemnified Brooklyn Navy Yard Cogeneration Partners, L.P. for any payments due under this settlement agreement which are scheduled through 2006. At March 31, 2003, EME recorded a liability of $12 million related to this indemnity.

Guarantee of 50% of TM Star Fuel Supply Obligations

        TM Star was formed for the limited purpose of selling natural gas to March Point Cogeneration Company, an affiliate through common ownership, under a fuel supply agreement that extends through December 31, 2011. TM Star has entered into fuel purchase contracts with unrelated third parties to meet a portion of the obligations under the fuel supply agreement. EME has guaranteed 50% of TM Star's obligation under the fuel supply agreement to March Point Cogeneration Company. Due to the nature of the obligation under this guarantee, a maximum potential liability cannot be determined. TM

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Star has met its obligations to March Point Cogeneration Company, and, accordingly, no claims against this guarantee have been made.

Capacity Indemnification Agreements

        EME has guaranteed, jointly and severally with Texaco Inc., the obligations of March Point Cogeneration Company under its project power sales agreements to repay capacity payments to the project's power purchaser in the event that the power sales agreements terminate, March Point Cogeneration Company abandons the project, or the project fails to return to normal operations within a reasonable time after a complete or partial shutdown, during the term of the power contracts. In addition, subsidiaries of EME have guaranteed the obligations of Kern River Cogeneration Company and Sycamore Cogeneration Company under their project power sales agreements to repay capacity payments to the projects' power purchaser in the event that the projects unilaterally terminate their performance or reduce their electric power producing capability during the term of the power contracts. The obligations under the indemnification agreements as of March 31, 2003, if payment were required, would be $200 million. EME has no reason to believe that any of these projects will either cease operations or reduce its electric power producing capability during the term of its power contract.

Bank Indemnity Under a Letter of Credit Supporting ISAB Energy's Debt Service Reserve Account

        EME has indemnified its lenders under its credit facilities from amounts drawn on a $35 million letter of credit issued for the benefit of the lenders to ISAB Energy, a 49% unconsolidated affiliate, in lieu of ISAB Energy funding a debt service reserve account using additional equity contributions. Accordingly, a default under ISAB Energy's project debt could result in a draw under the letter of credit which, in turn, would result in a borrowing under EME's credit facilities. The letter of credit is renewed each six-month period or until ISAB Energy funds the debt service account. The indemnification is subject to the maximum amount drawn under the letter of credit. EME has not recorded a liability related to this indemnity.

Subsidiary Indemnity to Central Maine Power Company for Value of Points of Delivery

        A subsidiary of EME has indemnified Central Maine Power Company against decreases in the value of power deliveries by CL Power Sales Eight, L.L.C., an unconsolidated affiliate, to Central Maine Power as a result of the implementation of a location-based pricing system in the New England Power Pool. The indemnity has the same term as a power supply agreement between Central Maine Power and CL Eight, which runs through December 2016. It is not possible to determine potential differences in values between the various points of delivery in New England Power Pool at this time. Due to the nature of this indemnity, a maximum potential liability cannot be determined. To the extent EME's subsidiary would be required to make a payment under this indemnity, it and EME are indemnified by Peabody Energy Corporation pursuant to the 2000 Purchase and Sale Agreement for the acquisition of Citizens Power LLC. EME's subsidiary has not recorded a liability related to this indemnity.

Subsidiary Guarantees for Performance of Unconsolidated Affiliates

        A subsidiary of EME has guaranteed the obligations of two unconsolidated affiliates to make payments to third parties for power delivered under fixed-price power sales agreements. These agreements run through 2008. EME believes there is sufficient cash flow to pay the power suppliers assuming timely payment by the power purchasers. Due to the nature of this indemnity, a maximum potential liability cannot be determined. To the extent EME's subsidiary would be required to make payments under the guarantee, EME's subsidiary and EME are indemnified by Peabody Energy Corporation pursuant to the 2000 Purchase and Sale Agreement for Citizens Power LLC. EME's subsidiary has not recorded a liability related to this indemnity.

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Environmental Matters and Regulations

        EME is subject to environmental regulation by federal, state and local authorities in the United States and foreign regulatory authorities with jurisdiction over projects located outside the United States. EME believes that it is in substantial compliance with environmental regulatory requirements and that maintaining compliance with current requirements will not materially affect its financial position or results of operation. However, possible future developments, such as the promulgation of more stringent environmental laws and regulations, and future proceedings that may be initiated by environmental authorities, could affect the costs and the manner in which EME conducts its business and could cause it to make substantial additional capital expenditures. There is no assurance that EME would be able to recover these increased costs from its customers or that EME's financial position and results of operations would not be materially adversely affected.

        Typically, environmental laws require a lengthy and complex process for obtaining licenses, permits and approvals prior to construction and operation of a project. Meeting all the necessary requirements can delay or sometimes prevent the completion of a proposed project as well as require extensive modifications to existing projects, which may involve significant capital expenditures. If EME fails to comply with applicable environmental laws, it may be subject to penalties and fines imposed against EME by regulatory authorities.

Note 8. Business Segments

        EME operates predominantly in one line of business, electric power generation, with reportable segments organized by geographic region: Americas, Asia Pacific and Europe. EME's plants are located in different geographic areas, which mitigate the effects of regional markets, economic downturns or unusual weather conditions.

Note 9. Investments

        The following table presents summarized financial information of the significant subsidiary investments in unconsolidated affiliates accounted for by the equity method. The significant subsidiary investments include the California Power Group, Watson Cogeneration Company, Four Star Oil & Gas Company, PT Paiton Energy and ISAB Energy S.r.l. The California Power Group (not a legal entity)

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consists of Kern River Cogeneration Company, Sycamore Cogeneration Company, Coalinga Cogeneration Company, Mid-Set Cogeneration Company, Salinas River Cogeneration Company, Sargent Canyon Cogeneration Company, and Sunrise Power Company, LLC.

Note 10. Supplemental Statements of Cash Flows Information

Note 11. Stock-based Compensation

        Edison International has three stock-based employee compensation plans, which are described more fully in Note 15—Stock Compensation Plans included in EME's annual report on Form 10-K for the year ended December 31, 2002. EME accounts for those plans under the recognition and measurement principles of APB Opinion No. 25, "Accounting for Stock Issued to Employees," and related interpretations. Upon grant, no stock-based employee compensation cost is reflected in net income, as all options granted under those plans had an exercise price equal to the market value of the underlying common stock on the date of grant. The following table illustrates the effect on net income (loss) if EME had used the fair value accounting method.

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Note 12. Changes in Accounting

Statement of Financial Accounting Standards No. 143

        Effective January 1, 2003, EME adopted Statement of Financial Accounting Standards No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is increased to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. As of January 1, 2003, EME recorded a $9 million, after tax, decrease to net income as the cumulative effect of adoption of SFAS No. 143.

        EME recorded a liability representing expected future costs associated with site reclamations, facilities dismantlement and removal of environmental hazards as follows:

        For the three months ended March 31, 2003, EME recognized accretion expense related to its asset retirement obligation of approximately $400,000. Had SFAS No. 143 been applied retroactively in the three months ended March 31, 2002, it would not have had a material effect upon EME's results of operations.

Statement of Financial Accounting Standards Interpretation No. 45

        In November 2002, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards Interpretation No. 45, "Guarantor's Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others." This interpretation establishes reporting requirements to be made by a guarantor about its obligations under certain guarantees that it has issued. It also clarifies that a guarantor is required to recognize, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee. The initial recognition and initial measurement provisions of this interpretation are applicable on a prospective basis to guarantees issued or modified after December 31, 2002. The adoption of this standard had no impact on EME's financial statements. See disclosure regarding guarantees and indemnities in Note 7—Commitments and Contingencies.

Statement of Financial Accounting Standards Interpretation No. 46

        In January 2003, the Financial Accounting Standards Board issued Statement of Financial Accounting Standards Interpretation No. 46, "Consolidation of Variable Interest Entities" (FIN 46). This interpretation of Accounting Research Bulletin No. 51, "Consolidated Financial Statements," addresses consolidation by business enterprises of variable interest entities. The primary objective of the Interpretation is to provide guidance on the identification of, and financial reporting for, entities over which control is achieved through means other than voting rights; such entities are known as variable-interest entities. This interpretation applies to variable interest entities created after January 31, 2003, and applies to variable interest entities in which EME holds a variable interest that it acquired before February 1, 2003, beginning July 1, 2003.

        Under FIN 46, an enterprise that will (1) absorb a majority of a variable interest entity's expected losses (if they occur), (2) receive a majority of a variable interest entity's expected residual returns (if they occur), or (3) both of the above, must consolidate the variable interest entity. The enterprise that

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consolidates the variable interest entity is called the primary beneficiary. EME believes it is reasonably possible that one or more of its investments in unconsolidated affiliates will be a variable interest entity. Accordingly, EME is in the process of making this determination, and for investments in unconsolidated affiliates which are variable interest entities, a further determination will be made if EME is the primary beneficiary.

        EME has concluded that it is the primary beneficiary of Brooklyn Navy Yard Cogeneration Partners L.P. since it is at risk with respect to a majority of its losses and is entitled to receive a majority of its residual returns. Accordingly, EME will consolidate Brooklyn Navy Yard Cogeneration Partners L.P. effective July 1, 2003. In accordance with the transition provisions of FIN 46, the consolidation of Brooklyn Navy Yard Cogeneration Partners L.P. will be based on the historical cost of the assets, liabilities and non-controlling interest which would have been carried by EME effective when EME became the primary beneficiary. This means that EME will consolidate the assets and liabilities of Brooklyn Navy Yard Cogeneration Partners L.P. using the June 30, 2003 balance sheet and eliminate intercompany balances. EME expects the consolidation of this entity to increase total assets by approximately $364 million and total liabilities by approximately $435 million. Furthermore, EME expects to record a loss of approximately $71 million as a cumulative change of accounting as a result of consolidating this variable interest entity. This loss is primarily due to cumulative losses allocated to the other 50% partner in excess of equity contributions recorded.

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ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF RESULTS OF OPERATIONS AND FINANCIAL CONDITION

        The following discussion contains forward-looking statements. These statements are based on Edison Mission Energy's (EME's) knowledge of present facts, current expectations about future events and assumptions about future developments. Forward-looking statements are not guarantees of performance; they are subject to risks, uncertainties and assumptions that could cause actual future activities and results of operations to be materially different from those set forth in this discussion. Important factors that could cause differences in EME's results of operations are set forth under "—Market Risk Exposures" below, and under "—Risk Factors" in the Management's Discussion and Analysis of Results of Operations and Financial Condition included in Item 7 of EME's annual report on Form 10-K for the year ended December 31, 2002.

        The Management's Discussion and Analysis of Results of Operations and Financial Condition of this Form 10-Q discusses material changes in the results of operations, financial condition and other developments of EME since December 31, 2002, and as compared to the three months ended March 31, 2002. This discussion presumes that the reader has read or has access to Management's Discussion and Analysis of Results of Operations and Financial Condition included in Item 7 of EME's annual report on Form 10-K for the year ended December 31, 2002.

General

        EME is an independent power producer engaged in the business of owning or leasing and operating electric power generation facilities worldwide. EME also conducts price risk management and energy trading activities in power markets open to competition. EME is a wholly owned subsidiary of Mission Energy Holding Company. Edison International is EME's ultimate parent company. Edison International also owns Southern California Edison Company, one of the largest electric utilities in the United States.

        As of March 31, 2003, EME owned or leased interests in 27 domestic and 54 international operating power plants with an aggregate generating capacity of 23,868 megawatts (MW), of which EME's share was 18,823 MW. At that date, one domestic and two international power plants, totaling 615 MW of generating capacity, of which EME's anticipated share will be approximately 308 MW, were under construction.

Current Developments

        A number of significant developments during late 2001 and 2002 adversely affected independent power producers and subsidiaries of major integrated energy companies that sell a sizable portion of their generation into the wholesale energy market (sometimes referred to as merchant generators), including several of EME's subsidiaries. These developments included lower market prices in wholesale energy markets both in the United States and United Kingdom, significant declines in the credit ratings of most major market participants, decreased availability of debt financing or refinancing, and a resulting decline of liquidity in the energy markets due to growing concern about the ability of counterparties to perform their obligations. Since the beginning of 2003, several merchant generators reached agreements to extend existing bank credit facilities.

        EME's largest subsidiary, Edison Mission Midwest Holdings, has $911 million of debt maturing in December 2003 which will need to be repaid, extended or refinanced. Edison Mission Midwest Holdings is not expected to have sufficient cash to repay the $911 million debt due in December 2003, and there is no assurance that Edison Mission Midwest Holdings will be able to extend or refinance its debt obligation on similar terms and rates as the existing debt, on commercially reasonable terms, on the terms permitted under the financing documents entered into by Mission Energy Holding Company in July 2001, or at all. EME's independent accountants' audit opinion for the year ended December 31,

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2002 contains an explanatory paragraph that indicates the consolidated financial statements have been prepared on the basis that EME will continue as a going concern and that the uncertainty about Edison Mission Midwest Holdings' ability to repay, extend or refinance this obligation raises substantial doubt about EME's ability to continue as a going concern. Accordingly, the consolidated financial statements do not include any adjustments that might result from the resolution of this uncertainty.

        During the first quarter of 2003, wholesale energy prices in the Pennsylvania-New Jersey-Maryland Power Pool, or PJM, increased primarily due to colder-than-normal weather and increases in the prices for natural gas. However, the recent changes in wholesale energy prices may or may not continue throughout 2003. See "—Market Risk Exposures" for more information regarding forward market prices.

Acquisitions and Dispositions of Investments in Energy Plants

Acquisitions

        On March 3, 2003, Contact Energy, EME's 51% owned subsidiary, completed a transaction with NGC Holdings Ltd. to acquire the Taranaki Combined Cycle power station and related interests. The Taranaki station is a 357 MW combined cycle, natural gas-fired plant located near Stratford, New Zealand. Consideration for the Taranaki station consisted of a cash payment of approximately $275 million, which was financed with bridge loan facilities. The bridge loan facilities were subsequently repaid with proceeds from the issuance of long-term U.S. dollar denominated notes.

Dispositions

        During the first quarter of 2002, EME completed the sales of its 50% interests in the Commonwealth Atlantic and James River projects and its 30% interest in the Harbor project. Proceeds received from the sales were $44 million. During 2001, EME recorded asset impairment charges of $32 million related to these projects based on the expected sales proceeds. No gain or loss was recorded from the sale of EME's interests in these projects during the first quarter of 2002.

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RESULTS OF OPERATIONS

CONSOLIDATED OPERATING RESULTS

Net Income (Loss) Summary

        Net loss is comprised of the following components:

        EME's loss from continuing operations for the first quarter of 2003 was $8 million compared to $41 million for the first quarter of 2002. The 2003 reduction in loss from continuing operations from 2002 was primarily due to higher PJM power prices and higher generation by EME's Homer City facilities, higher west coast energy prices and higher earnings from oil and gas activities.

Operating Revenues

        Operating revenues increased 27% for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase was primarily due to increased electric revenues from the Illinois Plants, Homer City facilities and Contact Energy.

        Net gains (losses) from price risk management and energy trading activities is comprised of:

        Net gains and (losses) from price risk management activities result from recording derivatives at fair value under Statement of Financial Accounting Standards No. 133, "Accounting for Derivative Instruments and Hedging Activities" (SFAS No. 133). Included in net gains (losses) from price risk management were:

•

$(8) million for the first quarter of 2003, related to the ineffective portion of Homer City forward electricity contracts, which are derivatives that qualify as cash flow hedges under SFAS No. 133, effective April 1, 2002.



•

$(6) million for the first quarter of 2003, related to the change in market value of electricity and financial contracts entered into by Contact Energy.



•

$(5) million for the first quarter of 2003 and $4 million for the first quarter of 2002, related to realized losses and the change in market value of long-term commodity contracts entered into by the First Hydro plant for the purchase and sale of electricity that is recorded at fair value under SFAS No. 133, with changes in fair value recorded through the income statement.

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        Under SFAS No. 133, the portion of a cash flow hedge that does not offset the change in value of the transaction being hedged, which is commonly referred to as the ineffective portion, is immediately recognized in earnings. EME recorded a net loss of approximately $8 million and $1 million during the first quarters of 2003 and 2002, respectively, representing the amount of cash flow hedges' ineffectiveness. The net losses during the first quarter of 2003 are attributable to increases in the difference between energy prices at PJM West Hub (where EME's subsidiary enters into forward contracts) and the energy prices at the delivery point where power generated by the Homer City facilities is delivered into the transmission system (referred to as the Homer City busbar). See "—Market Risk Exposures—Americas" for more information regarding forward market prices.

        The 2003 net gains from energy trading activities were primarily the result of net gains from transmission congestion contracts and other power contracts in markets where EME has power plants. The 2002 net gains from energy trading activities primarily represent the completion of the restructuring of a power sales agreement with an unaffiliated electric utility. As part of the transaction, an EME subsidiary purchased the power sales agreement held by a third party, modified its terms and conditions, and entered into a long-term power supply agreement with another party. Although the sale and purchase of power arising from these contracts will occur over their term, net gains of $17 million were recorded during the first quarter of 2002 attributable to the fair value of the contracts (generally referred to as mark-to-market accounting).

        EME's third quarter electric revenues are materially higher than revenues related to other quarters of the year because warmer weather during the summer months results in higher electric revenues being generated from the Homer City facilities and the Illinois Plants. By contrast, the First Hydro plants have higher electric revenues during their winter months.

Operating Expenses

        Fuel costs increased $72 million for the first quarter of 2003, compared to the first quarter of 2002. Fuel costs in 2003 increased primarily due to increased generation from the Illinois Plants and the Homer City facilities.

        Plant operations and transmission costs increased $20 million for the first quarter of 2003, compared to the first quarter of 2002. Transmission costs were $55 million and $36 million for the first quarters of 2003 and 2002, respectively. The 2003 increase in transmission costs was primarily due to higher retail sales generated by Contact Energy.

        Depreciation and amortization expense increased $14 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase is primarily due to higher amortization expense resulting from the adoption of SFAS No. 142 at Contact Energy. In addition, depreciation expense increased in the first quarter of 2003 from the first quarter of 2002, resulting from the termination of the Midwest Generation equipment lease in August 2002.

        Administrative and general expenses decreased $7 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 decrease was primarily due to cost reductions implemented in 2002. During the first quarter of 2002, EME severance and other related costs were $4 million.

Other Income (Expense)

        Equity in income from unconsolidated affiliates increased 21% for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase was primarily due to an increase in EME's share of income from the Big 4 projects and Four Star Oil & Gas. EME's third quarter equity in income from its domestic energy projects is materially higher than equity in income related to other quarters of the year due to warmer weather during the summer months and because a number of

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EME's domestic energy projects, located on the west coast, have power sales contracts that provide for higher payments during the summer months.

        Interest and other income decreased $3 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 decrease was primarily due to lower interest income.

        Interest expense increased $4 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase was due to higher interest costs at the Illinois Plants due to a downgrade of the credit rating of Edison Mission Midwest Holdings and higher levels of borrowings at Contact Energy. See "—Liquidity and Capital Resources—Credit Ratings."

Income Taxes

        EME's annual effective tax rate (excluding state tax reallocation benefits) was 41% in the first quarter of 2003 compared to 47% in the first quarter of 2002. During the first quarter of 2003, EME recorded $5 million of additional state tax benefits net of federal income taxes, as a result from participation in a tax-allocation agreement with Edison International.

Minority Interest

        Minority interest expense decreased $1 million for the first quarter of 2003, compared to the first quarter of 2002. Minority interest primarily relates to 49% ownership of Contact Energy by the public in New Zealand.

Discontinued Operations

Lakeland Project

        EME's Lakeland project operated a 220 MW combined cycle, natural gas-fired power plant located in the United Kingdom. The assets of the project are owned by EME's indirect subsidiary, Lakeland Power Ltd., which sold power generated from the plant pursuant to a power sales agreement with Norweb Energi Ltd., a subsidiary of TXU (UK) Holdings Limited (TXU UK) and an indirect subsidiary of TXU Europe Group plc (TXU Europe).

        On December 19, 2002, the lenders to the Lakeland project accelerated the debt owing under the bank agreement that governs the project's indebtedness, and on December 20, 2002, the Lakeland project lenders appointed an administrative receiver over the assets of Lakeland Power Ltd. The administrative receiver was appointed to take control of the affairs of Lakeland Power Ltd. and has a wide range of powers (specified in the Insolvency Act), including authorizing the sale of the power plant. The appointment of the administrative receiver requires the treatment of Lakeland power plant as an asset held for sale under Statement of Financial Accounting Standards No. 144, "Accounting for the Impairment or Disposal of Long-Lived Assets" (SFAS No. 144). Due to EME's loss of control arising from the appointment of the administrative receiver, EME no longer consolidates the activities of Lakeland Power Ltd. The consolidated financial statements have been restated to conform to discontinued operations treatment for all historical periods presented.

        On April 22, 2003, a third party announced that it had entered an agreement with the administrative receiver to purchase the Lakeland power plant for £24 million. Subject to satisfaction of closing conditions, completion of the sale is expected during the second quarter of 2003.

        During the first quarter of 2002, EME recorded income of $5 million from discontinued operations primarily related to operating income from the Lakeland power plant.

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Cumulative Effect of Change in Accounting Principle

Statement of Financial Accounting Standards No. 142

        Effective January 1, 2002, EME adopted Statement of Financial Accounting Standards No. 142, "Goodwill and Other Intangible Assets." SFAS No. 142 establishes accounting and reporting standards requiring goodwill not to be amortized but rather tested for impairment at least annually at the reporting unit level. EME will perform its annual evaluation of goodwill on October 1, 2003 or sooner if indicators of impairment exist. During the third quarter of 2002, EME concluded that fair value of the goodwill related to the Citizens Power LLC acquisition was impaired by $14 million, net of $9 million of income tax benefit and, accordingly, reported this amount as a cumulative change in accounting. In accordance with SFAS No. 3, "Reporting Accounting Changes in Interim Financial Statements," EME's financial statements for the first quarter of 2002 were restated to reflect the accounting change as of January 1, 2002.

Statement of Financial Accounting Standards No. 143

        Effective January 1, 2003, EME adopted Statement of Financial Accounting Standards No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred. When the liability is initially recorded, the entity capitalizes a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is increased to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss upon settlement. As of January 1, 2003, EME recorded a $9 million, after tax, decrease to net income as the cumulative effect of the adoption of SFAS No. 143.

REGIONAL OPERATING RESULTS

        EME operates predominantly in one line of business, electric power generation, organized by three geographic regions: Americas, Asia Pacific, and Europe. Operating revenues are derived from EME's majority-owned domestic and international entities. Intercompany interest expense and income between EME and its consolidated subsidiaries have been eliminated in the following project results, except as described below with respect to loans provided to EME from a wholly owned subsidiary, Midwest Generation. Equity in income from unconsolidated affiliates relates to energy projects where EME's ownership interest is 50% or less in the projects. The equity method of accounting is generally used to account for the operating results of entities over which EME has a significant influence but in which it does not have a controlling interest. With respect to entities accounted for under the equity method, EME recognizes its proportional share of the income or loss of such entities.

        EME uses the words "earnings" or "losses" in this section to describe income or loss from continuing operations before income taxes and minority interest.

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Americas

Illinois Plants

(1)

The availability factor is determined by the number of megawatt-hours the coal plants are available to generate electricity divided by the product of the capacity of the coal plants (in megawatts) and the number of megawatt-hours in the period. The coal plants are not available during periods of planned and unplanned maintenance.

(2)

The forced outage rate is generally referred to as unplanned maintenance.

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        In accordance with the power purchase agreements, Exelon Generation released 4,548 MW of generating capacity during 2002 from the power purchase agreements at the Illinois Plants. Of the generating capacity released by Exelon Generation, EME's subsidiary suspended operations for 1,370 MW and decommissioned 45 MW. As a result, beginning in 2003, the Illinois Plants have 3,133 MW available for sale as merchant generation. Operating revenues from the Illinois Plants increased $46 million for the first quarter of 2003, compared to the first quarter of 2002, primarily due to increased merchant generation at the coal plants released by Exelon Generation. Operating revenues were also higher due to average realized energy prices from merchant generation due to colder-than-normal weather, partially offset by lower capacity revenue from the reduction in megawatts contracted under the power purchase agreements. The average realized prices from merchant generation during the first quarter of 2003 were less than the actual spot market prices during that period due to forward contracts entered into during 2002 (prior to the increase in spot market prices that took place during the first quarter of 2003) for approximately 52% of the Illinois Plants' actual merchant generation. See "—Market Risk Exposures—Illinois Plants."

        Exelon Generation is obligated under the power purchase agreements to make capacity payments for the plants under contract (4,739 MW during 2003) and energy payments for electricity produced by these plants. As a result of the decline in contracted generating capacity under the power purchase agreements, revenues from Exelon Generation as a percentage of EME's consolidated operating revenues decreased from 30% for the first quarter of 2002 to 19% for the first quarter of 2003. Revenues from Exelon Generation were $131 million and $161 million for the first quarters of 2003 and 2002, respectively. For more information on the power purchase agreements and wholesale energy markets, see "—Market Risk Exposures—Illinois Plants."

        Losses from the Illinois Plants decreased $2 million for the first quarter of 2003, compared to the first quarter of 2002, due to the following factors:

•

higher revenues as described above, partially offset by additional fuel costs related to higher generation and higher fuel prices at the Collins Station.



•

lower plant operations costs primarily due to lower labor costs resulting from cost reductions implemented in the fourth quarter of 2002 and lower employee benefit costs.

        The losses of the Illinois Plants included interest income of $28 million and $31 million for the first quarters of 2003 and 2002, respectively, related to loans to EME. In August 2000, Midwest Generation, which owns or leases the Illinois Plants, entered into a sale-leaseback transaction of the Powerton-Joliet facilities. The proceeds from the sale of these facilities were loaned to EME, which also provided a guarantee of the related lease obligations of Midwest Generation. The Powerton-Joliet sale-leaseback is recorded as an operating lease for accounting purposes.

Homer City

(1)

The availability factor is determined by the number of megawatt-hours the coal plants are available to generate electricity divided by the product of the capacity of the coal plants (in megawatts) and

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the number of megawatt-hours in the period. The coal plants are not available during periods of planned and unplanned maintenance.

(2)

The forced outage rate is generally referred to as unplanned maintenance.

        Operating revenues from Homer City increased $63 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase primarily resulted from higher electric revenues from the Homer City facilities due to increased generation and higher energy prices. On February 10, 2002, Homer City experienced a major unplanned outage due to a collapse of the SCR ductwork of one of the units, known as Unit 3. The unit was restored to operation on April 4, 2002 and is operating with the SCR bypassed.

        Earnings from Homer City increased $44 million for the first quarter of 2003, compared to the first quarter of 2002. The 2003 increase in earnings is due to increased generation and higher energy prices. See "—Market Risk Exposures—Homer City Facilities."

        Losses from price risk management activities were $8 million for the first quarter of 2003. The losses primarily represent the ineffective portion of forward contracts which are derivatives that qualify as cash flow hedges under SFAS No. 133. No comparable amount was recorded the first quarter of 2002. See "—Consolidated Operating Results—Operating Revenues" for further discussion.

Big 4 Projects

        EME owns partnership investments (50% ownership or less) in Kern River Cogeneration Company, Midway-Sunset Cogeneration Company, Sycamore Cogeneration Company and Watson Cogeneration Company. These projects have similar economic characteristics and have been used, collectively, to secure bond financing by Edison Mission Energy Funding Corp., a special purpose entity that EME includes in its consolidated financial statements. Due to similar economic characteristics and the bond financing related to EME's equity investments in these projects, EME evaluates them collectively and refers to them as the Big 4 projects.

        Earnings from the Big 4 projects increased $16 million for the first quarter of 2003, compared to the first quarter of 2002. The change in earnings was largely due to higher energy prices in 2003. The earnings from the Big 4 projects included interest expense from Edison Mission Energy Funding of $4 million and $5 million for the first quarters of 2003 and 2002, respectively.

Four Star Oil & Gas

        EME owns a 37.2% direct and indirect interest, with 36.05% voting stock, in Four Star Oil & Gas Company, with majority control held by affiliates of ChevronTexaco Corporation. Four Star Oil & Gas owns oil and gas reserves in the San Juan Basin, the Hugoton Basin, the Permian Basin and offshore Gulf Coast and Alabama. EME's share of earnings from Four Star Oil & Gas Company was $15 million and $7 million for the first quarters of 2003 and 2002, respectively. The 2003 increase in earnings was primarily due to higher natural gas prices.

Other

        Earnings from other projects in the Americas region (consolidated subsidiaries and unconsolidated affiliates) included net gains from energy trading activities of $15 million and $17 million for the first quarters of 2003 and 2002, respectively. See "—Consolidated Operating Results—Operating Revenues" for further discussion.

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Asia Pacific